Investigation of the dynamic capillary pressure during displacement process in fractured tight rocks

Li, Ying; Li, Haitao; Chen, Shengnan; Luo, Hongwen; Liu, Chang

doi:10.1002/aic.16783

Cited by 28 publications

(13 citation statements)

References 76 publications

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“…16,30,31 Therefore, this issue is particularly investigated in this work through displacement tests on water-wet fractured tight cores. • A contact angle advancement coefficient is proposed to identify the significance of contact angle advancement and forces competition.…”

Section: Key Pointsmentioning

confidence: 99%

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Dynamic capillarity during displacement process in fractured tight reservoirs with multiple fluid viscosities

Luo

et al. 2019

Energy Science & Engineering

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Dynamic capillarity commonly exists for multiphase flow in porous media, during which fluid viscosity varies and has strong influence. Displacement experiments are conducted on water-wet, fractured tight rock at in situ pressure and temperature of an oil reservoir via a specially designed apparatus to investigate the effects of fluid viscosity on the dynamic capillarity. The dynamic effect in the matrix is examined through the measurement and calculation of capillary pressure, the dynamic coefficient, and the fluid flow behavior. The results show that with a higher oil viscosity:(a) both the steady and the dynamic capillary pressures reverse their directions more quickly and behave as larger resistances in the matrix; (b) the difference between the steady and the dynamic capillary pressures becomes around 5%-19% more significant; (c) water saturation changes more slowly corresponding to the lower water relative permeability, while oil relative permeability quickly becomes lower than that during the basic displacement process; and (d) the dynamic coefficient becomes 2-3 times higher, and the dynamic contact angle becomes 10%-25% larger, showing a more variable interface. A contact angle advancement coefficient is proposed to identify the significance of contact angle advancement and the competition between capillary pressure and viscous force. The findings of this study can help for better understanding of multiphase flow in tight reservoirs and enhancing oil recovery.

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Section: Key Pointsmentioning

confidence: 99%

“…fluid flow behavior. 16,30,31 Therefore, this issue is particularly investigated in this work through displacement tests on water-wet fractured tight cores. Specially designed apparatus is employed to determine the dynamic capillary pressure during the displacement processes in fractured tight rock samples.…”

Section: Key Pointsmentioning

confidence: 99%

Dynamic capillarity during displacement process in fractured tight reservoirs with multiple fluid viscosities

Luo

et al. 2019

Energy Science & Engineering

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“…Until now, subcore scale flow and transport behavior in heterogeneous porous media has focused on sandstones characterized by the presence of bedding planes, laminae, and/or fractures (Corey & Rathjens, 1956;Hingerl et al, 2016;Kim et al, 2018;Krevor et al, 2011;Li et al, 2019;Manzocchi et al, 2002;Medina et al, 2011;Pasala et al, 2013;Shipton et al, 2002;Tueckmantel et al, 2012). Relatively little attention has been given to experimentally understanding the impact of deformation bands on fluid flow.…”

Section: Introductionmentioning

confidence: 99%

Subcore Scale Fluid Flow Behavior in a Sandstone With Cataclastic Deformation Bands

Romano

Zahasky

Garing

et al. 2020

Water Resources Research

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Accurate determination of petrophysical and multiphase flow properties in sandstones is necessary for reservoir characterization, for instance for carbon dioxide and hydrogen storage in geological formations or for enhanced oil recovery. Several studies have examined the effect of heterogeneities, such as fractures, bedding planes, and laminae, on core-scale fluid flow. However, the influence of deformation bands that commonly occur in high porosity sandstones is poorly understood. In this study, we consider a core sample of Navajo sandstone characterized by diagonally oriented deformation bands and two laminae perpendicular to the core axis, as determined from micro X-ray computed tomography (micro-CT). Positron emission tomography is used to derive the single phase hydrodynamic properties of the core. A CO 2 drainage experiment is conducted in the water-saturated core and imaged with a medical X-ray CT scanner. Medical CT enables CO 2 saturation quantification with increasing CO 2 injection rate. Experimental results and the accompanying numerical simulations indicate that both the laminae and the deformation bands act as capillary barriers, with the laminae forming weaker capillary barriers than the deformation bands. The deformation bands have lower permeability and porosity due to grain crushing, and a very high capillary entry pressure that inhibits CO 2 migration across the bands. At the reservoir scale, deformation bands form conjugate sets and are often present in thick anastomosing clusters that define lozenge-shaped compartments. These findings have important consequences for subsurface fluid flow. For example, the presence of deformation bands may reduce the storage capacity and injectivity in carbon storage reservoirs.

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“…Wang et al 22 studied the spontaneous and forced imbibition characteristics in tight cores using NMR. Li et al 23 investigated the dynamic capillary pressure during the displacement process in fractured tight rocks, and the results have shown that the dynamic capillary pressure of the matrix becomes around 5%‐20% higher after the fracturing treatment. In tight oil reservoirs, the physical and chemical properties of the pore throats are poor, and the physical and chemical properties of the material on the surface of the pores change due to the small pore‐throat size, which makes the fluid interact strongly with the surface of the core channel, and thin layers of fluid are adsorbed on the surface of the pores, thus forming a boundary layer 24‐26 .…”

Section: Introductionmentioning

confidence: 99%

Characteristics of imbibition in tight oil reservoirs from the perspective of physical experiments and theory

Cao

Liu

et al. 2020

Energy Science & Engineering

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Investigation of the dynamic capillary pressure during displacement process in fractured tight rocks

Cited by 28 publications

References 76 publications

Dynamic capillarity during displacement process in fractured tight reservoirs with multiple fluid viscosities

Dynamic capillarity during displacement process in fractured tight reservoirs with multiple fluid viscosities

Subcore Scale Fluid Flow Behavior in a Sandstone With Cataclastic Deformation Bands

Characteristics of imbibition in tight oil reservoirs from the perspective of physical experiments and theory

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